Field of the Invention
[0001] This invention relates generally to a method and apparatus for collecting data regarding
geological properties of underground or undersea formations in the vicinity of a well
bore under construction. More particularly, this invention relates to a method and
apparatus for collecting data regarding the formations during and after drilling and
constructing the well bore. In particular, the invention relates to a method and apparatus
for collecting data regarding the formations sensors, actuators and generators coupled
to a well casing inside the well bore. This invention also relates to a method and
apparatus for relaying data collected deep in a well to the surface.
Background of the Invention
[0002] Geologists and geophysicists collect data regarding underground formations in order
to predict the location of hydrocarbons such as oil and gas. Traditionally, such information
is gathered during an exploration phase. In recent years, however, the art has advanced
to allow the collection of geophysical and geological data as a well is being drilled.
[0003] For example, in Vertical Seismic Profiling ("VSP"), drilling operations are interrupted
to place a series of seismic sensors at discrete depths in a borehole. A surface source
releases energy that is reflected off underground geological formations. The seismic
sensors in the borehole sense the reflected energy and provide signals representing
reflections to the surface for analysis.
[0004] In a subsequent development, known as "drill bit seismic", seismic sensors are positioned
at the surface near the borehole to sense seismic energy imparted to the earth by
the drill bit during drilling, see for example
US-A-4.207.619. This sensed energy is used in the traditional seismic way to detect reflections
from underground geological formations. Further, this technique is used to detect
"shadows", or reduced seismic energy magnitude, caused by underground formations,
such as gas reservoirs, between the drill bit and the surface sensors.
[0005] A greatly simplified description of those steps involved in drilling an oil well
follows. A portion of the oil well is drilled using a drill string consisting of drill
pipe, drill collars and drill bit. After a portion of the well has been drilled, a
section of casing, or large bore pipe, is inserted into the well bore and cemented
for, among other things, zonal isolation. Casing performs a number of functions, including:
preventing the bore hole from caving in; preventing fluids in the bore hole from contaminating
the surrounding formations; preventing the introduction of water into the surrounding
formations; containing any production from the well; facilitating pressure control;
providing an environment for the installation of production equipment; and providing
zonal isolation.
[0006] When the casing is in place it is cemented to the formation wall. This is accomplished
by pumping cement through the casing until it exits at the end of the casing through
a special section of casing called a "casing shoe" and flows up the annulus between
the casing and the wall of the well bore. The concrete is then allowed to set.
[0007] In subsequent drilling operations, the deep end of the newly cemented casing is drilled
out and another section of the well bore is drilled. The process of drilling sections
of the well bore followed by inserting and cementing well casing repeats until the
desired well depth is reached.
[0008] As the well bore is being drilled, drilling fluids, known as "mud", are pumped into
the drill string. The mud travels down the drill string until it is ejected. The mud
picks up cuttings and carries them to the surface. The specific gravity of the drill
mud is carefully controlled so that the weight of the column of mud is (1) large enough
to prevent gas or other hydrocarbons from entering the borehole from the surrounding
formations; (2) without exerting so much pressure that the surrounding formations
are damaged.
[0009] After each section of casing is laid and cemented in, the fracture pressure of the
formation just below the end of the casing is measured. Generally, the fracture pressure
of deeper formations is greater than the fracture pressure of shallower formations.
The specific gravity of the drilling mud is subsequently controlled to make sure that
the pressure on the formation at the end of the casing does not exceed the fracture
pressure of the formation at that point. This is generally accomplished by calculations
incorporating the measured specific gravity of the drilling mud and the depth of the
column of drilling mud above the formation.
[0010] Downhole data are captured using "wireline" techniques in which, prior to casing
being laid, a tool, such as an acoustic logging tool, is lowered into the well bore
and slowly retrieved, gathering data and storing it or transmitting it to the surface
as the tool is being retrieved. Alternatively, measurement while drilling ("MWD")
or logging while drilling ("LWD") tools are attached to the drill string just above
the drill bit and drill collars. These generally expensive tools gather-data during
the drilling process and store it or transmit it to the surface.
[0011] United States Patent No. 5,265,680 describes a system for installing instruments near the bottom of a well by modifying
a float shoe to provide a protective housing for an instrument.
United States Patent No. 5,467,823 describes a system in which a pressure sensor such as a pressure gauge is fixed on
the outer surface of a well casing at a depth corresponding to a non-producing reservoir.
An explosive charge is fired adjacent the pressure sensor that perforates a surrounding
reservoir and puts the fluid of the reservoir in communication with the pressure sensor.
United States Patent No. 5,131,477 describes a system for avoiding well intersections during the drilling of a new well
in the vicinity of existing wells in which vibrations generated in the process of
drilling the new well are detected by a vibration detector coupled to the wellhead
of the existing well or wells. International Publication No.
WO 98/12417A describes a system in which a string of pipe inserted into a well includes a pipe
provided with a sensor.
United States Patent No. 5,363,094 describes a system for monitoring an effluent deposit including sensors installed
in the annular space between a well casing and a tubing. International Publication
Number
WO 98/50680A describes a system in which fiber optic sensors are used to monitor conditions in
a well bore.
United States Patent No. 4,839,644 describes a two-way wireless telemetry system for communicating between a downhole
communications apparatus and an uphole communications apparatus.
United States Patent No. 5,868,201 describes a downhole production well control system for automatically controlling
downhole tools in which the automatic control is initiated downhole.
International Publication No. WO 97/49894 describes a system in which a sensor device may be mounted in a casing string. An
article entitled "
Field Measurements of Annular Pressure and Temperature During Primary Cementing" by
C.E. Cooke, Jr., M.P. Kluck and R. Medrano (Journal of Petroleum Technology, August
1983) describes an experiment in which temperature and pressure sensors were attached
at intervals to the outside of a production casing.
Summary of the Invention
[0012] In general, in one aspect, the invention features a casing sensor comprising a casing
shoe and a sensor coupled to the casing shoe.
[0013] Implementations of the invention may include one or more of the following. The sensor
may comprise a pressure sensor. The sensor pressure may comprise a pressure transducer
and a transmitter coupled to the pressure transducer. The casing sensor may comprise
a surface receiver coupled to the transmitter. The casing sensor may comprise a drill
string through the casing shoe.
[0014] In general, in another aspect, the invention features a casing data relay comprising
a downhole receiver coupled to a well casing and a transmitter coupled to the receiver.
Implementations of the invention may include one or more of the following. The casing
data relay may comprise a surface receiver coupled to the transmitter. The surface
receiver may be electrically or optically coupled to the transmitter. The surface
receiver may be coupled to the transmitter by electromagnetic telemetry. The surface
receiver may be coupled to the transmitter by a pressure transducer. The casing data
relay may comprise an antenna coupled to the downhole receiver, the antenna being
configured to receive electromagnetic radiation. The casing data relay may comprise
one or more casing sensors coupled to the casing, wherein one or more of the one or
more casing sensors are coupled to the transmitter. The casing data relay may comprise
one or more drill string sensors coupled to a drill string. At least a portion of
the drill string may be inserted through the casing. The drill string sensors may
be coupled to the downhole receiver. One or more of the drill string sensors may be
coupled to the downhole receiver through a drill string transmitter. The casing data
relay may comprise drill string instruments coupled to the transmitter and a surface
transmitter coupled to the downhole receiver. The casing data relay may comprise a
drill string actuator. The drill string actuator may be controllable through the downhole
receiver. The drill string actuator may be configured to change a position of an adjustable
gauge stabilizer. The drill string actuator may be configured to change a bit nozzle
size.
[0015] In general, in another aspect, the invention features a method for collecting geological
data comprising sensing one or more geological parameters during drilling using one
or more sensors coupled to a well casing in a well bore, collecting data from the
one or more sensors and transmitting the data to the surface. Sensing may comprise
sensing using one or more sensors coupled to a casing shoe, sensing using a pressure
transducer on a casing shoe, sensing pressure, sensing temperature, sensing acoustic
energy, sensing stress or sensing strain. The method may further comprise transmitting
acoustic energy. Transmitting may comprise transmitting the data to the surface through
a relay.
[0016] In general, in another aspect, the invention features a method for maintaining the
integrity of a formation in the vicinity of a casing shoe comprising measuring well
bore pressure in the vicinity of the casing shoe during drilling.
[0017] Implementations of the invention may include one or more of the following.
The method may comprise transmitting data representing the measured well bore pressure
to the surface.
[0018] In general, in another aspect, the invention features a method for positioning look
ahead sensors comprising positioning acoustic sensors along a casing string.
[0019] In general, in another aspect, the invention features a method for monitoring well
control events comprising monitoring pressure at two or more locations inside a casing
of the well.
[0020] Implementations of the invention may include one or more of the following. Monitoring
may comprise monitoring pressure at two or more locations that are longitudinally
displaced along the casing.
[0021] In general, in another aspect, the invention features a method for determining whether
cement in a well borehole has cured comprising positioning a temperature sensor on
a casing and monitoring the temperature of the cement using the temperature sensor.
[0022] Implementations of the invention may include one or more of the following.
Positioning may comprise positioning the temperature sensor inside the casing or positioning
the temperature sensor on the casing shoe.
Brief Description of the Drawing
[0023]
Fig. 1 is a cross-section view of a drilling operation.
Fig. 2 is a cross-section view of casing being inserted into a well.
Fig. 3 is a perspective view of a section of casing according to the present invention.
Fig. 4 is a perspective view of a section of casing according to the present invention
during the cementing operation.
Fig. 5 is a perspective view of a section of casing according to the present invention.
Fig. 6 is a perspective view of a section of casing according to the present invention
after drilling has pierced the end of the casing.
Fig. 7 is a block diagram of a system according to the present invention.
Fig. 8 is a block diagram of a system according to the present invention.
Description of the Preferred Embodiments
[0024] An apparatus for monitoring geological properties and drilling parameters and for
facilitating seismic while drilling comprises sensors, actuators and generators coupled
to the casing. The sensors allow the collection and transmission to the surface of
geological data and critical drilling parameters (such as hydraulic measurements,
downhole weight on bit, and downhole torque) from shortly after the casing is inserted
until the data is no longer needed. The actuators and generators facilitate the collection
of data and are controllable from the surface. The apparatus also provides a relay
for data transmitted from deeper in the well bore or from MWD or LWD tools. The equipment
relays data between the surface and the sensors, actuators and generators deep in
the well.
[0025] As shown in Fig. 1, a drilling rig 10 (simplified to exclude items not important
to this application) comprises a derrick 12, derrick floor 14, draw works 16, hook
18, swivel 20, kelly joint 22, rotary table 24, drillstring 26, drill collar 28, LWD
tool 30, LWD tool 32 and drill bit 34. Mud is injected into the swivel by a mud supply
line 38. The mud travels through the kelly joint 22, drillstring 26, drill collars
28, and LWD tools 30 and 32 and exits through jets or nozzles in the drill bit 34.
The mud then flows up the borehole 40. A mud return line 42 returns mud from the borehole
40 and circulates it to a mud pit (not shown) and back to the mud supply line 38.
The combination of the drill collar 28, LWD tool 30, LWD tool 32 and drill bit 34
is known as the bottomhole assembly 36 (or "BHA").
[0026] The data collected by the LWD tools 30 and 32 is returned to the surface for analysis
by, for example, telemetry transmitted through the drilling mud. A telemetry transmitter
44 located in a drill collar or in one of the LWD tools collects data from the LWD
tools and modulates the data to transmit it through the mud. A telemetry sensor 46
on the surface detects the telemetry and returns it to a demodulator 48. The demodulator
48 demodulates the data and provides it to computing equipment 50 where the data is
analyzed to extract useful information.
[0027] After the well has been drilled to a certain depth, has shown in Fig. 2, a length
of casing 52 is lowered into the well bore in sections. The first section 54, called
a "casing shoe", has a specialized purpose, as will be discussed below. As it is being
lowered, the section of casing is suspended from casing hangar 56, which hangs from
the hook 18.
[0028] When the casing 52 has been fully inserted into the borehole, as shown in Fig. 3,
the casing shoe 54 comes to rest at or near the bottom of the well bore. A centralizer
58 keeps the casing centered in the borehole. Signal-carrying cable 60 connects a
cable tie-in 62 to equipment on the surface. The cable 60 and cable tie-in 62 allow
a connection between the surface and sensors, actuators and generators in the casing
shoe, as will be discussed below. Further, cable 60 provides connections between sensors,
actuators and generators located along the casing (not shown in Fig. 3) to the casing
shoe 54. Wireline anchor bands 64 secure the cable 60 to the casing.
[0029] After the casing is position, it is cemented into place, as shown in Fig. 4.
Cement is pumped down through the casing to the casing shoe where it escapes through
port 66. The cement 68 flows up the annulus between the casing and the surrounding
formations 70.
[0030] When sufficient concrete has been poured to serve its intended purpose, the concrete
is allowed to set, as shown in Fig. 5. As concrete sets, its temperature varies. By
monitoring the temperature of the concrete using temperature sensor 72, personnel
at the surface can determine when the concrete has set sufficiently to go into the
next step in the drilling process. Information from the temperature sensor 72 is transferred
to the surface through cable tie-in 62 and cable 60. Additional temperature sensors
may be placed at other locations to monitor the temperature of the concrete.
[0031] The next step in the drilling process, shown in Fig. 6, is to drill out casing 52.
Drill bit 74 penetrates the end of casing shoe 54 and continues the well bore. As
drilling continues, mud is pumped down through the center of the drillstring 76 and
out jets or nozzles in the drill bit 74. The mud 78 picks up cuttings and carries
them back to surface along the annulus between the drill string and formation and
then along the annulus between the drillstring 76 and casing 52.
[0032] As discussed above, the specific gravity of the mud is carefully controlled to assure
that the pressure exerted by the mud on the formation does not exceed the fracture
pressure of formation. The pressure exerted by the mud on the formation is monitored
by a pressure sensor 80 located in the casing shoe. Its location in the casing shoe
allows pressure sensor 80 to monitor the pressure on the weakest formation just below
the casing shoe.
[0033] Personnel on the surface monitor the signals from the pressure sensor, which are
sent to the surface through the cable tie-in 62 and cable 60. If they determine that
the specific gravity of the mud must be increased because of the danger of a "kick",
or influx of formation fluids into the borehole, and the planned increase will raise
the pressure exerted by the mud beyond the fracture pressure of the formation, they
may decide to stop drilling and insert another section of casing.
[0034] In addition to the pressure sensor and temperature sensor that were discussed above,
additional sensors are located along the casing to provide a variety of other functions.
For example, an array of acoustic sensors and/or geophones may be located along a
portion of the casing to receive acoustic energy from the formation through the concrete
surrounding the casing. Such acoustic sensors could be used in conjunction with acoustic
energy generators located in the MWD tools for accomplishing MWD acoustic logging.
The acoustic energy generator could be attached to the casing, allowing long term
monitoring of the acoustic characteristics of the formations surrounding the borehole.
An acoustic energy generator attached to the casing could also be used as a source
for acoustic energy measurements in another nearby well.
[0035] Similarly, the acoustic sensors could be used to detect acoustic energy generated
by surface generators or by acoustic sources in other nearby wells. The acoustic sensors
could be used during drilling and after the well is completed and is in production
or after it has been shut in.
[0036] Acoustic sensors coupled to the casing can also be used in support of "look-ahead"
technology, in which acoustic signals are used to detect geological features ahead
of the drill bit. With the acoustic sensors coupled to the casing, the look-ahead
performance improves over a look-ahead system employing surface acoustic sensors because
the acoustic sensors coupled to the casing are closer to the geological features being
detected.
[0037] In addition to pressure sensors, temperature sensors and acoustic sensors and generators,
stress and strain sensors may be located along the casing to measure the stress and
strain to be experienced by the formations surrounding the casing. Again, the stress
sensors and strain sensors can be used during drilling and after the well has been
completed and has been placed in production or has been shut in.
[0038] In another application of sensors, two or more pressure sensors could be strategically
located at various depths along the inside of the casing. Such an arrangement of pressure
sensors could detect the dynamic changes in pressure associated with a kick. For example,
detection of dropping pressure at successively shallower pressure sensors could indicate
that a gas kick has occurred. Advance warning of such an event would allow personnel
on the surface to engage blowout preventers to reduce the chance of injury to the
surface equipment or personnel.
[0039] In general, any sensor that provides useful information regarding the formations
surrounding the well can be attached to the casing. Further, any actuator or generator
that produces useful signals, energy or actions to be used in measuring the properties
of the formations or in monitoring the drilling process may also be attached to the
casing.
[0040] The placement of the sensors, actuators and generators is illustrated in Fig. 7.
The well shown in Fig. 7 includes a surface casing 82, an intermediate casing 84,
and a drill string 86. A set of surface casing sensors, actuators and generators 88
is coupled to the surface casing 82. A set of intermediate casing sensors, actuators
and generators 90 is coupled to the intermediate casing 84. Depending on their purpose,
the sensors, actuators and generators may be attached to the inside of the casing
or the outside of the casing. The sensors, actuators and generators may be welded
to the casing or attached by bands or through special annular fittings that affix
them to the inside or the outside of the casing in such a way that they do not interrupt
the flow of fluids through or around the casing.
[0041] A set of MWD tool sensors, actuators and generators 92 is coupled to the drill string
86. For example, if the MWD tool is an acoustic-logging tool, it would include acoustic
energy generators (transmitters) and acoustic energy sensors (receivers). Other types
of tools would include other types of sensors and generators. The MWD tool sensors,
actuators and generators 92 may provide, for example, the capability to change the
position of an adjustable gauge stabilizer or to change the bit nozzle size or to
activate any actuator attached to the drill string.
[0042] The sensors, actuators and generators communicate with the surface in one or more
of several ways. First, each sensor, actuator or generator may have a cable connection
to the surface. For example, the surface casing sensors, actuators and generators
88 may communicate with surface equipment 94 via cable 96 and the intermediate casing
sensors, actuators and generators 90 may communicate with the surface equipment 94
via cable 98. Alternatively, some or all of the surface casing sensors, actuators
and generators 88 may communicate with a surface casing controller 100, coupled to
the surface casing 82, which gathers data provided by the surface casing sensors,
formats it and communicates it to the surface equipment 94 via cable 98. Surface equipment
94 may transmit commands or other data to the surface casing sensors, actuators and
generators 88 directly or through the surface casing controller 100.
[0043] Similarly, some or all of the intermediate casing sensors, actuators and generators
90 may communicate with an intermediate casing controller 102, coupled to the intermediate
casing 84, which gathers data provided by the intermediate casing sensors, formats
it and transmits it to the surface equipment 94. Surface equipment 94 may transmit
commands or other data to the intermediate casing sensors, actuators and generators
90 directly or through the intermediate casing controller 102.
[0044] Cables 96 and 98 can be any kind of cable, including electrical cable or optical
fiber cable. Further, the information carried by the cable can be sent using any information
transmission scheme, including baseband, modulated (amplitude modulation, frequency
modulation, phase modulation, pulse modulation or any other modulation scheme), and
multiplexed (time-division multiplexed, frequency-division multiplexed or any other
multiplexing scheme, including the use of spread spectrum techniques). Consequently,
each sensor, actuator or generator may communicate with the surface equipment via
its own communication media which is part of cables 96 and 98 or each set 88 and 90
may share a communication media that is part of cables 96 and 98, respectively. Further,
cables 96 and 98 may be coupled to allow the surface casing sensors, actuators and
generators to share the use of the communication medium formed by the combination
of the two cables 96 and 98.
[0045] Alternatively, communication between the surface casing controller 100 and the surface
equipment 94 may be by radio frequency transmission or pulse telemetry transmission.
In the case of radio frequency transmission, an antenna 104 extends from the surface
casing controller 100 that allows radio frequency communication between it and the
surface equipment 94, which would communicate the RF energy via an antenna 106. In
the case of pulse telemetry transmission, the surface casing controller 100 and the
surface equipment 94 each include a transducer 108 and 110 (see Fig. 8), respectively,
that convert data into acoustic pulses and vice versa. The acoustic energy travels
through the casing 82, the mud or any other medium that will allow the transmission
of acoustic energy. The RF energy and the acoustic energy can be modulated or multiplexed
in any of the ways described above. Further, the communication between the surface
casing controller 100 and the surface equipment 94 may be done through a combination
of communication through the cable, through RF transmission and through pulse telemetry.
[0046] Communication between the intermediate casing controller 102 and the surface equipment
94 can be by any of the methods described above for the communication between the
surface casing controller 100 and the surface equipment 94. An antenna 112 is coupled
to the intermediate casing controller 102 to allow RF communication. An acoustic transducer
114 (see Fig. 8) is coupled to the intermediate casing controller 102 to allow pulse
telemetry communication. Alternatively, the surface casing controller 100 can serve
as a relay between the intermediate casing controller 102 and the surface equipment
94. In this situation, the intermediate casing controller 102 communicates with the
surface casing controller 100 using any of the communication techniques discussed
above, including communicating by cable, by RF transmission or by pulse telemetry.
The surface casing controller 100 communicates with the surface equipment 94 as discussed
above.
[0047] The MWD tool sensors, actuators and generators 92 communicate with the surface equipment
94 through a drill string controller 116. The drill string controller 116 compiles
data from the MWD tool sensors, actuators and generators 92 and transmits the data
to the surface equipment 94. The surface equipment 94 transmits commands and other
data to the MWD tool sensors, actuators and generators 92 through the drill string
controller 116. The communication between the surface equipment 94 and the drill string
controller 116 may be relayed through the intermediate casing controller 102 and the
surface casing controller 100. Alternatively, the drill string controller 116 may
only use one of the surface casing controller 100 or the intermediate casing controller
102 as a relay. The communication between the drill string controller 116 and the
surface equipment 94 may use any of the information transmission schemes described
above. An antenna 118 is coupled to the drill string controller 116 to allow RF communication.
An acoustic transducer 120 (see Fig. 8) is coupled to the drill string controller
116 to allow pulse telemetry communication.
[0048] Fig. 8 illustrates all of the communication paths possible among the various sensors,
actuators, generators, controllers and surface equipment. In the preferred embodiment,
the surface casing sensors, actuators and generators 88 communicate with the surface
casing controller 100 which communicates with the surface equipment 94 over cable
96. Alternatively: (a) one or more of the surface casing sensors, actuators and generators
88 may communicate directly with the surface equipment 94, as indicated by dotted
line 122; (b) communication between the surface casing controller 100 and the surface
equipment 94 may be by RF signals using antennas 104 and 106 or by pulse telemetry
using acoustic transducers 108 and 110.
[0049] In the preferred embodiment, the intermediate casing sensors, actuators and generators
communicate with the intermediate casing controller 102 which communicates with the
surface equipment 94 by RF signals using antennas 104 and 112 or by pulse telemetry
using acoustic transducers 108 and 114. Alternatively: (a) one or more of the intermediate
casing sensors, actuators and generators 90 may communicate directly with the surface
equipment 94, as indicated by dotted line 124; (b) communication between the intermediate
casing controller 102 and the surface equipment 94 may be by way of cable 98 (shown
as a dotted line).
[0050] In the preferred embodiment, the drill string sensors, actuators and generators 92
communicate directly with the drill string controller 116, which may be part of an
MWD tool or some other piece of drill string equipment. The drill string controller
116 communicates with the surface equipment 94 through antenna 118 and/or acoustic
transducer 120 directly or using the intermediate casing controller 102 and/or the
surface casing controller 100 as relays.
[0051] The foregoing describes preferred embodiments of the invention and is given by way
of example only. The invention is not limited to any of the specific features described
herein, but includes all variations thereof within the scope of the appended claims.